WO2014044843A2

WO2014044843A2 - Downhole apparatus and methods

Info

Publication number: WO2014044843A2
Application number: PCT/EP2013/069709
Authority: WO
Inventors: Niall Lipp
Original assignee: Interwell As
Priority date: 2012-09-24
Filing date: 2013-09-23
Publication date: 2014-03-27
Also published as: NO20121079A1; WO2014044843A3

Abstract

There is provided a toolstring comprising at least a first downhole tool and a second downhole. The toolstring is configured to set the first downhole tool at a first location and the second downhole tool at a second location in a single run. The second downhole tool is movable with the toolstring from the first location to the second location between setting the first downhole tool and setting the second downhole tool. There is provided an associated method of setting at least the first downhole tool and the second downhole tool in a single run.

Description

DOWNHOLE APPARATUS AND METHODS

FIELD OF THE INVENTION

The present invention relates to a method of setting first and second downhole tools in a bore downhole and a downhole toolstring. BACKGROUND TO THE INVENTION

In downhole operations, such as in bores for reservoirs (e.g. oil and gas reservoirs), one or more downhole tools are often required to be set or retrieved.

A downhole tool, such as a plug, is usually set with a running tool during a run into a bore and then retrieved using a separate pulling tool. Often it is desired to set or retrieve multiple tools in a single bore. For example, when plugging a well, such as temporarily between operations or permanently, it is sometimes desirable to set at least two plugs. Typically a first plug is set with a running tool towards the bottom of a bore during a first run-in. The running tool is retrieved to the surface and a second plug is attached to the running tool. The running tool is run into the bore again, such as to a lesser depth than the first plug, and the second plug is set. Accordingly the second plug is usually set nearer the surface during a second run-in.

Sometimes the tools are temporarily set; for example to temporarily isolate a portion of a well (e.g. to allow an upper portion of a wellbore to be treated or during a bridging operation). After setting the tool with a running tool, the running tool is retrieved to the surface. After completion of the operation, the tool is then unset and retrieved using a fishing tool run in from the surface. During other operations, the tool may be permanently set, such as during plug and abandon operations.

SUMMARY OF THE INVENTION

According to an aspect of the invention, there is provided a method of setting first and second downhole tools in a bore comprising:

running a first downhole tool and a second downhole tool on one toolstring into a bore;

setting the first downhole tool at a first location;

moving the second downhole tool relative to the set first downhole tool to a second location; and

setting the second downhole tool at the second location.

The method may comprise setting the first and second downhole tools in a single run. The single run may comprise a single trip into the bore. The single run may comprise not retrieving the toolstring (e.g. not retrieving the toolstring to surface between setting the first and second downhole tools). The single run may comprise not pulling the toolstring to surface. The single run may comprise a single downhole deployment of the toolstring. The single run may comprise running in multiple branches of a bore (without pulling from the bore).

The method may comprise setting one or both of the first and/or second tools substantially independently of the other of the first and second tools.

The method may comprise running in the first and second downhole tools simultaneously.

The method may comprise moving the second downhole tool relative to the set first downhole tool subsequent to setting the first downhole tool. The method may comprise setting the second downhole tool subsequent to setting the first downhole tool. The method may comprise setting the second downhole tool subsequent to moving the second downhole tool relative to the first downhole tool.

The method may comprise moving the second downhole tool axially relative to the first location. The method may comprise moving the second downhole tool with the toolstring to the second location.

The second location may be remote from the first location. The second location may be independent of the first location. The second location may be uphole of the first location. The second location may be downhole of the first location. The first and/or second location/s may be in a wellbore branch/es.

The second location may be at a distance from the first location. The distance may be selectable (e.g. an operator may selectively activate the setting of the first and/or second tool/s). The distance may be predetermined (e.g. the distance may be based upon a preset parameter, such as a preset distance and/or preset time). The distance may be based upon a measured parameter (e.g. a measured depth).

The first and second downhole tools may be mounted on the toolstring at a transportation distance for running in and/or out. The transportation distance may be substantially different from the distance between the first and second locations (e.g. substantially greater than the distance between the first and second locations).

Setting may comprise locking the respective first and second downhole tools at each location (e.g. to a casing and/or a wellbore and/or downhole equipment). Setting may comprise actuating a gripping and/or a sealing arrangement/s (e.g. slips and/or a seal). Setting may comprise radial expansion. Setting may comprise attachment to a casing and/or a wellbore and/or downhole equipment. The method may comprise moving the second downhole tool with the toolstring. For example, the method may comprise moving the toolstring to move the second downhole tool relative to the set first downhole.

The method may comprise disconnecting the first downhole tool from the toolstring prior to moving the second downhole tool to the second location.

The method may comprise decoupling the first downhole tool from the toolstring prior to moving the second downhole tool to the second location.

The method may comprise detaching the first downhole tool from the toolstring prior to moving the second downhole tool to the second location.

The method may comprise setting the first and/or second downhole tool/s with a setting arrangement. The method may comprise setting the first downhole tool with a first setting system of the setting arrangement (e.g. a first setting or running tool). The method may comprise setting the second downhole tool with a second setting system of the setting arrangement (e.g. a second setting or running tool).

The method may comprise disconnecting and/or detaching and/or decoupling at least a portion of the setting arrangement from the toolstring. For example, the method may comprise disconnecting at least a portion of the first setting system from the toolstring (and optionally substantially the entire first setting system).

The method may comprise disconnecting and/or detaching and/or decoupling at least a portion of the setting arrangement from the toolstring during or after setting the first downhole tool.

The method may comprise disconnecting and/or detaching and/or decoupling at least a portion of the setting arrangement from the toolstring prior to moving the second downhole tool to the second location.

The method may comprise disconnecting and/or detaching and/or decoupling at least a portion of the setting arrangement from the toolstring after moving the second downhole tool to the second location. The method may comprise disconnecting and/or detaching and/or decoupling at least a portion of the setting arrangement from the toolstring during or after setting the second downhole tool. For example, the method may comprise disconnecting and/or detaching and/or decoupling at least a portion of the first setting system from the toolstring during or after setting the second downhole tool.

The method may comprise disconnecting and/or detaching and/or decoupling a further portion (e.g. at least a portion of the first and/or second setting system) of the setting arrangement from the toolstring after moving the second downhole tool to the second location.

The method may comprise disconnecting and/or detaching and/or decoupling the further portion of the setting arrangement from the toolstring during or after setting the second downhole tool.

The method may comprise disconnecting and/or detaching and/or decoupling the second downhole tool from the toolstring. The method may comprise disconnecting and/or detaching and/or decoupling the second downhole tool from the toolstring during or after setting the second downhole tool.

The method may comprise mechanically disconnecting and/or detaching and/or decoupling. The method may comprise mechanically disconnecting and/or detaching and/or decoupling, whilst maintaining an auxiliary connection. For example, the method may comprise mechanically disconnecting a portion of the setting arrangement and/or the first downhole tool such that a weight of the portion and/or the downhole tool is not supported by the toolstring, while maintaining an auxiliary connection (e.g. a fluid and/or signal connection).

The method may comprise disconnecting and/or detaching and/or decoupling at least a portion of the setting arrangement (e.g. the first setting system and/or a portion of the first setting system) by a predefined mechanical failure (e.g. of the setting arrangement). The mechanical failure may comprise a tensile failure. Additionally, or alternatively, the failure may comprise a shear failure. The mechanical failure may comprise an axial failure. The method may comprise mechanically failing at a predefined mechanical weakness.

The method may comprise providing a distance between portions separated by a mechanical failure, such as an axial distance. The method may comprise preventing contact between at least two surfaces created by the mechanical failure subsequent to the mechanical failure. The method may comprise preventing contact between a surface/s created by the mechanical failure and other surfaces (e.g. all other surfaces of toolstring and/or tool components and/or wellbore surfaces, such as casing). Preventing contact may prevent or inhibit damage to other surfaces and/or the likelihood of debris creation and/or debris contamination of the wellbore and/or equipment, such as the toolstring (e.g. compared to a use of a shear pin).

The method may comprise unsetting the first and/or the second downhole tools. The method may further comprise unsetting the first and/or the second downhole tools in a single run. The method may comprise setting and unsetting the first and/or the second downhole tools in a single run.

The method may comprise retrieving the first and/or the second downhole tools. The method may further comprise retrieving the first and/or the second downhole tools in a single run. The method may further comprise setting and retrieving the first and/or the second downhole tools in a single run.

The method may comprise connecting at least a portion of the setting arrangement to the first and/or second downhole tool/s.

The method may comprise unsetting at least the first downhole tool from the first location and the second downhole tool from the second location in a single run.

The method may comprise retrieving the first and second downhole tools in a single run.

The method may comprise not retrieving the toolstring between unsetting the second and the first downhole tools. The method may comprise leaving the toolstring downhole between unsetting the second and the first downhole tools.

The method may comprise reconfiguring the toolstring between a setting configuration and an unsetting configuration. The method may comprise reconfiguring the toolstring downhole. The method may comprise automatically reconfiguring the toolstring. The method may comprise reconfiguring the toolstring from the setting configuration to the unsetting configuration by setting the downhole tool. Reconfiguring the toolstring may comprise reconfiguring the setting arrangement. The unsetting configuration may comprise a retrieval (or fishing) configuration.

The method may comprise retrieving the first and second downhole tools simultaneously (e.g. running out the first and second downhole tools on the toolstring, such as from the second location).

The method may comprise setting additional downhole tools. For example, the method may comprise setting a third downhole tool (e.g. located on the toolstring above the second downhole tool).

According to an aspect of the invention there is provided a downhole toolstring comprising first and second downhole tools, wherein the toolstring is configured to set the first downhole tool at a first location in a bore and the second downhole tool at a second location in the bore, the second downhole tool being movable relative to the set first downhole tool at the first location to the second location. The second downhole tool may be movable relative to the first location to the second location between setting the first downhole tool and setting the second downhole tool.

The bore may comprise an open-drilled bore, a lined or cased drilled bore. The bore may be of a tubing string, pipeline or the like.

The toolstring may comprise an elongate body. The toolstring may comprise wireline. The toolstring may comprise slickline. The toolstring may comprise E-line. The toolstring may comprise coiled tubing. The toolstring may comprise a casing, a tubular, a pipeline, or the like.

The toolstring may comprise a common toolstring. For example, the first and second downhole tools may be mounted on the same toolstring (e.g. to a same elongate body).

The toolstring may be configured to move from the first location to the second location (e.g. between setting the first and second tools). The second downhole tool may be movable with the toolstring relative to the first downhole tool. For example, the elongate body may be pulled subsequent to setting the first downhole tool, to pull the second downhole tool to the second location.

The first and/or second downhole tool/s may comprise a plug.

The first and/or second downhole tool/s may comprise a packer.

The first and/or second downhole tool/s may comprise a valve.

The first and/or second downhole tool/s may comprise a flow control device.

The first and/or second downhole tool/s may comprise a hanger (e.g. a gauge hanger).

The first and/or second downhole tool/s may comprise a straddle.

The first and/or second downhole tool/s may comprise a tubing puncher.

The first and/or second downhole tool/s may be actuatable substantially independently of setting and/or unsetting. For example, the downhole tool/s may be actuated after setting. The first and second downhole tools may be actuatable substantially simultaneously. For example, the first and second downhole tools may be actuated by a signal. The first and second downhole tools may be actuatable substantially independently of the other. For example, the first downhole tool may be actuated by a first signal, and the second downhole tool may be actuated by a discrete second signal.

The toolstring may be configured to unset the first and/or the second downhole tools. The toolstring may be configured to unset the first and second tools in a single unsetting run. The unsetting run may be the same as the setting run. The toolstring may be configured to set and unset the first and/or the second downhole tools in a single run.

The toolstring may be configured to set at least the first downhole tool at the first location and the second downhole tool at the second location in a single run.

The toolstring may comprise a setting arrangement for setting the first and second downhole tools.

The toolstring may be configured to unset at least the first downhole tool at the first location and the second downhole tool at the second location in a single run.

The toolstring may be configured to retrieve the first and/or the second downhole tools. The toolstring may be configured to retrieve at least the first downhole tool from the first location and the second downhole tool from the second location in a single retrieval run. The retrieval run may be the same as the setting and/or unsetting run. The toolstring may be configured to set and retrieve the first and/or the second downhole tools in a single rerun.

The toolstring may be configured to set and unset at least the first downhole tool at the first location and/or the second downhole tool at the second location in a single run.

The toolstring may be configured to set and retrieve at least the first downhole tool from the first location and/or the second downhole tool from the second location in a single run.

The toolstring may be configured to set and unset at least the first downhole tool at the first location and set the second downhole tool at the second location in a single run.

The toolstring may be configured to set at least the first downhole tool at the first location and set and unset the second downhole tool at the second location in a single run.

The toolstring may be configured to not retrieve the toolstring between setting and unsetting the first and/or second downhole tools. The toolstring may be configured to leave the toolstring downhole between setting and unsetting.

The toolstring may be configured to not retrieve the toolstring between unsetting the second and the first downhole tools. The toolstring may be configured to leave the toolstring downhole between unsetting the second and the first downhole tools. The toolstring may be configured to retrieve the first and second downhole tools simultaneously (e.g. run out the first and second downhole tools on the toolstring, such as from the second location).

The setting arrangement may comprise a first setting system configured to set the first downhole (e.g. a first setting or running tool).

The setting arrangement may comprise a second setting system configured to set the second downhole tool (e.g. a second setting or running tool).

The first setting system may be discrete from the second setting system.

The first setting system may be configured to set the second downhole tool. The first setting system may comprise or be integral with the second setting system (e.g. the first setting system may extend through or bridge the first and/or second downhole tool/s).

The first and/or second downhole tool/s may comprise a through bore.

The first setting system may comprise an adaptor. The first setting system may be positioned between the first and second downhole tools. The first setting system may be intermediate the first and second downhole tools.

The first setting system may be mounted to the second downhole tool and/or to the second setting system. For example, the first setting system may be mounted downhole of the second downhole tool. The first setting system may be coupled to the second downhole tool (e.g. rigidly coupled). The first setting system may be connected to the second setting system (e.g. mechanically and/or fluidly and/or via a communication means, such as a control line or signal transmitter/receiver).

The first setting system may be configured to be set downhole together with the second downhole tool. For example, the toolstring may be configured such that the first setting system is detached from the toolstring when the second downhole tool is detached.

The toolstring may be configured to leave the first setting system downhole (e.g. at the second location) whilst the second setting system is at least partially retrieved.

The toolstring may be configured to disconnect and/or decouple and/or detach the first downhole tool from the toolstring prior to moving the second downhole tool to the second location.

The toolstring may be configured to disconnect and/or decouple and/or detach the second downhole tool from the toolstring. The toolstring may be configured to disconnect and/or decouple and/or detach the second downhole tool from the toolstring during or after setting the second downhole tool.

The toolstring may be configured to disconnect and/or decouple and/or detach at least a portion of the setting arrangement from the toolstring.

The toolstring may be configured to disconnect and/or decouple and/or detach at least the portion of the setting arrangement (e.g. the first setting system and/or a portion of the first setting system) by a predefined mechanical failure (e.g. of the setting arrangement). The mechanical failure may comprise a tensile failure. The mechanical failure may comprise an axial failure. The toolstring may comprise a predefined mechanical weakness for controlling the mechanical failure. The mechanical weakness may comprise a reduced strength portion (e.g. a reduced material strength property; and/or a reduced dimension such as thickness or cross-sectional area). The mechanical weakness may be at least partially annular. The mechanical weakness may be a shear neck.

The toolstring may be configured to disconnect and/or decouple and/or detach at least a portion of the setting arrangement from the toolstring prior to moving the second downhole tool to the second location. The toolstring may be configured to disconnect and/or decouple and/or detach at least a portion of the setting arrangement from the toolstring during or after setting the first downhole tool. For example, the toolstring may be configured to disconnect and/or decouple and/or detach at least a portion of the first setting system from the toolstring during or after setting the first downhole tool.

The toolstring may be configured to disconnect and/or decouple and/or detach a further portion (e.g. a portion of the first and/or second setting system) of the setting arrangement from the toolstring after moving the second downhole tool to the second location. The toolstring may be configured to disconnect and/or decouple and/or detach at least a portion of the setting arrangement from the toolstring after moving the second downhole tool to the second location. The toolstring may be configured to disconnect and/or decouple and/or detach at least a portion of the setting arrangement from the toolstring during or after setting the second downhole tool. For example, the toolstring may be configured to disconnect and/or decouple and/or detach at least a portion of the first setting system from the toolstring during or after setting the second downhole tool.

The toolstring may be configured to provide a distance between portions separated by a mechanical failure, such as an axial distance. The toolstring may be configured to prevent contact between at least two surfaces created by the mechanical failure subsequent to the mechanical failure. The toolstring may be configured to prevent contact between a surface/s created by the mechanical failure and other surfaces (e.g. all other surfaces of toolstring and/or tool components and/or wellbore surfaces, such as casing). Preventing contact may prevent or inhibit damage to other surfaces and/or the likelihood of debris creation and/or debris contamination of the wellbore and/or equipment, such as the toolstring (e.g. compared to a use of a shear pin).

The toolstring may comprise an auxiliary connection. For example, the toolstring may be configured to mechanically disconnect a portion of the setting arrangement and/or the first downhole tool while maintaining an additional connection (e.g. a fluid and/or signal connection).

The toolstring may be configured to connect at least a portion of the setting arrangement to the first and/or second downhole tool/s. The toolstring may be configured to selectively releasably connect at least a portion of the setting arrangement to the first and/or second downhole tool/s. The toolstring may be configured to repeatedly connect at least a portion of the setting arrangement to the first and/or second downhole tool/s.

The toolstring may be configured to selectively release a portion of the setting arrangement and/or the first and/or second downhole tool/s, such as selectively release during retrieval. For example, where a lower downhole tool (e.g. the first downhole tool) becomes stuck in a bore (e.g. due to undesired slip extension, or a narrowing or deviation in the bore); the first downhole tool may be released - allowing the retrieval of the remainder of the toolstring. The released downhole tool may be retrieved subsequently (e.g. with another tool during another run); or left downhole (e.g. to be drilled or milled through). It may be desirable to release a portion of the setting arrangement and/or the first and/or second downhole tool/s during retrieval at a selected location. For example, the first downhole tool may be released at the second or another location during retrieval. Release may comprise setting.

The mechanical failure may comprise a tensile failure. The mechanical failure may comprise an axial failure. The toolstring may comprise a predefined mechanical weakness for controlling the mechanical failure. The mechanical weakness may comprise a reduced strength portion (e.g. a reduced material strength property; and/or a reduced dimension such as thickness or cross-sectional area). The mechanical weakness may be at least partially annular. The mechanical weakness may be a shear neck.

The toolstring may be configured for use with prior art equipment, such as prior art downhole tools. For example, the toolstring may comprise coupling means and/or setting actuation means compatible with existing downhole tools (e.g. box/threaded connectors, or the like).

The second setting system (and/or an additional setting system) may comprise any or all of the features recited for the first setting system, with respect to the second (or an additional) downhole tool. For example, the second setting system may comprise a second mechanical weakness.

According to an aspect of the invention, there is provided a method of unsetting at least a first downhole tool from a first location and a second downhole tool from a second location in a single run, the method comprising:

running in a toolstring;

unsetting the second downhole tool at the second location;

moving the second downhole tool to the first location;

unsetting the first downhole tool at the first location; and

simultaneously running out the first downhole tool and the second downhole tool on the toolstring.

According to an aspect of the invention there is provided a toolstring comprising at least a first downhole tool and a second downhole, wherein the toolstring is configured to unset the first downhole tool at a first location and the second downhole tool at a second location in a single run, the second downhole tool being movable from the second location to the first location between unsetting the second tool and unsetting the first tool.

According to an aspect of the invention there is provided a method of setting and unsetting a downhole tool in a single run, the method comprising:

running in a downhole tool on a toolstring to a downhole location;

setting the downhole tool; and

unsetting the downhole tool.

The method may comprise at least partially retrieving the toolstring between setting and unsetting the downhole tool (e.g. with the downhole tool set and optionally detached from the toolstring).

The method may comprise performing an operation between setting and unsetting the downhole tool. For example, the operation may comprise a test (e.g. a pressure test) to gauge a setting effect of the set downhole tool. The method may comprise performing the operation without retrieving the toolstring (e.g. to surface).

The method may comprise setting the downhole tool with a setting arrangement of the toolstring. The method may comprise unsetting the downhole tool with the setting arrangement of the toolstring.

The method may comprise reconfiguring the downhole tool between a setting configuration and an unsetting configuration. The method may comprise reconfiguring the setting arrangement downhole. The method may comprise automatically reconfiguring the setting arrangement. The method may comprise reconfiguring the setting arrangement from the setting configuration to the unsetting configuration by setting the downhole tool.

Accordingly, it may not be necessary to retrieve the toolstring to surface to be replaced by a fishing tool; or to be reconfigured to a fishing configuration. Allowing the toolstring to remain in the bore between setting and unsetting can save time or expense.

The method may comprise retrieving the downhole tool with the toolstring in the single run.

The method may comprise relocating the downhole tool to a second location. The second location may be downhole of the first location. The second location may be uphole of the first location. The second location may be in a branch bore of a bore comprising the first location (or vice versa). The method may comprise re-setting the downhole tool (e.g. redeploying). The method may comprise re-setting the downhole tool in a single run. The method may comprise re-setting the downhole tool without retrieving the toolstring to surface.

According to an aspect of the invention there is provided a downhole setting arrangement configured to set a first downhole tool at a first location and a second downhole tool at a second location in a single run, wherein the setting arrangement is movable from the first location to the second location between setting the first and second downhole tools.

According to an aspect of the invention there is provided a toolstring configured to set and unset a downhole tool in a single run, wherein the toolstring is optionally configured to be at least partially retrievable between setting and unsetting.

According to an aspect of the invention there is provided a setting tool configured to set and retrieve a downhole tool. The setting tool may be configured to set and retrieve the downhole tool in a single run. The setting tool may be configured to set and retrieve the downhole tool without retrieving the setting tool between setting and retrieval of the downhole tool. The setting tool may be configured to be partially retrieved between setting and retrieval of the downhole tool (e.g. retrieved to an uphole location, without returning to the surface). The setting tool may be reconfigurable between a setting configuration and an unsetting configuration. The setting tool may be configured to be positioned on a toolstring downhole of a second downhole tool.

The invention includes one or more corresponding aspects, embodiments or features in isolation or in various combinations whether or not specifically stated (including claimed) in that combination or in isolation. For example, it will readily be appreciated that features recited as optional with respect to the first aspect may be additionally applicable with respect to the other aspects without the need to explicitly and unnecessarily list those various combinations and permutations here (e.g. the setting arrangement of one aspect may comprise features of any other aspect). Optional features as recited in respect of a method may be additionally applicable to an apparatus; and vice versa.

In addition, corresponding means for performing one or more of the discussed functions are also within the present disclosure.

It will be appreciated that one or more embodiments/aspects may be useful in setting and/or retrieving downhole tools. It will also be appreciated that where first and second downhole tools are described, one or more embodiments/aspects may comprise additional downhole tools (e.g. third, and/or fourth, etc).

The above summary is intended to be merely exemplary and non-limiting.

BRIEF DESCRIPTION OF THE DRAWINGS

These and other aspects of the present invention will now be described, by way of example only, with reference to the accompanying drawings, in which:

Figure 1 shows a schematic view of a toolstring in accordance with a first embodiment of the invention, with the toolstring located in a bore uphole of a first location prior to setting;

Figure 2 shows the toolstring of Figure 1 at the first location prior to setting a first downhole tool;

Figure 3 shows the toolstring of Figure 1 at a second location prior to setting a second downhole tool;

Figure 4 shows the toolstring of Figure 1 uphole of the second location after setting the second downhole tool; Figure 5 shows the toolstring of Figure 1 uphole of the second location prior to unsetting the second downhole tool;

Figure 6 shows the toolstring of Figure 1 at the second location after unsetting the second downhole tool;

Figure 7 shows the toolstring of Figure 1 at the first location prior to unsetting the first downhole tool;

Figure 8 shows the toolstring of Figure 1 uphole of the first location after unsetting the first downhole tool;

Figure 9 shows a view of a toolstring in accordance with a second embodiment of the invention, with the toolstring located in a bore uphole of a setting location prior to setting a downhole tool;

Figure 10 shows the toolstring of Figure 9 at the setting location prior to setting the downhole tool;

Figure 1 1 shows the toolstring of Figure 9 uphole of the first location after setting the first downhole tool;

Figure 12 shows the toolstring of Figure 9 at the first location after unsetting the first downhole tool;

Figure 13 shows the toolstring of Figure 9 uphole of the first location after unsetting the first downhole tool;

Figure 14 shows a portion of a toolstring in accordance with a third embodiment of the invention, with the toolstring portion in a first configuration, prior to setting a first downhole tool;

Figure 15 shows the toolstring portion of Figure 14 with the toolstring in a second configuration setting the first downhole tool;

Figure 16 shows the toolstring portion of Figure 14 with the toolstring in a third configuration with a first setting tool partially decoupled from the first downhole tool;

Figure 17 shows the toolstring portion of Figure 14 with the toolstring in a fourth configuration with the first setting tool fully decoupled from the first downhole tool;

Figure 18 shows the toolstring portion of Figure 14 with the toolstring in a fifth configuration with the first setting tool partially recoupled to the first downhole tool;

Figure 19 shows the toolstring portion of Figure 14 with the toolstring in a sixth configuration with the first setting tool partially recoupled to the first downhole tool;

Figure 20 shows the toolstring portion of Figure 14 with the toolstring in a seventh configuration with the first setting tool partially recoupled to the first downhole tool; and Figure 21 shows the toolstring portion of Figure 14 with the toolstring in an eighth configuration with the first setting tool fully recoupled to the first downhole tool.

DETAILED DESCRIPTION OF THE DRAWINGS

Figure 1 shows a schematic view of a toolstring 10 in accordance with a first embodiment of the invention, with the toolstring 10 located in a bore 12 uphole of a first location 14 prior to setting.

The toolstring 10 has a first downhole tool 16, which is at a lowermost end 18 of the string 10 in the embodiment shown. The toolstring 10 has a second downhole tool 20 located uphole of the first downhole tool 16. The toolstring 10 has a setting arrangement 22, which comprises a first setting system 24 and a second setting system 26 in the embodiment shown. The first setting system 24 is located between the first and second downhole tools 16, 20. The second setting system 26 is located above the second downhole tool 20. In the embodiment shown, each setting system 24, 26 comprises a setting adaptor coupled to a setting tool.

The toolstring 10 is shown in Figure 1 in an uphole location in a setting configuration, prior to setting. The first downhole tool 16 is attached to a lower end of the first setting system 24. The first setting system 24 is attached to a lower end of the second downhole tool 20. The second downhole tool 20 is attached to a lower end of the second setting system 26. In the embodiment shown, the first and second downhole tools 16, 20 and the setting arrangement 22 form an end portion of the toolstring 10. In other embodiments (not shown) it will be appreciated that the setting arrangement and downhole tools may be arranged at other portions of a toolstring. For example, the toolstring may extend downhole of the first downhole tool 16, such as to additional downhole tools forming part of the toolstring.

In use, the toolstring 10 is run into the bore 12 in the configuration shown in Figure 1 . Upon reaching the first location 14, the first downhole tool 16 is set, as shown in Figures 2 and 3. The first location 14 is predetermined, such as by using timing, distance or depth actuation of the setting. In alternative embodiments, setting actuation may be controlled, such as by a signal (e.g. from surface).

Figure 2 shows the toolstring 10 at the first location 14, with first and second downhole tools 16, 20 and the first setting system 24 and the second setting system 26 still attached. To transition from Figure 2 to Figure 3, the first downhole tool 16 is set using the first setting system 24. The first downhole tool 16 is locked to the bore 12. The first setting system 24 is detached from the first downhole tool 16; and the toolstring 10 is pulled to the second location 28, as shown in Figure 3. Setting the first downhole tool 16 with the first setting system 24 reconfigures the first setting system 24 from a setting configuration to an unsetting or fishing configuration. The first setting system 24 is still attached to the second downhole tool 20, forming part of the toolstring 10, in Figure 3.

At the second location 28 in Figure 3, the second downhole tool 20 is set using the second setting system 26. The first setting system 24 remains attached to the second downhole tool 20, as the second downhole tool 20 is detached from the second setting system 26. As shown in Figure 4, after setting and detaching the second downhole tool 20, the toolstring 10 comprises the second setting system 26; with the first downhole tool 16 detached at the first location 14; and the second downhole tool 20 and the first setting system 24 detached at the second location 28. The toolstring 10 is pulled to a location uphole of the second location 28, as shown in Figure 4.

Setting the second downhole tool 20 with the second setting system 26 reconfigures the second setting system 26 from a setting configuration to an unsetting or fishing configuration. Accordingly, the toolstring 10 as shown in Figure 5 comprises a fishing or retrieval tool, with the second setting system 26 configured to unset the second downhole tool 20.

To unset the second downhole tool 20, the toolstring 10 is run in from the uphole location of Figure 5 to the second location 28 of Figure 6. It is not necessary to retrieve the toolstring 10 to surface to be replaced by a fishing tool, or to be reconfigured to a fishing configuration. Allowing the toolstring to remain in the bore 12 between setting and unsetting can save time or expense. The second setting system 26 in its unsetting configuration engages the set second downhole tool 20, and releases the second downhole tool 20 from its locking engagement with the bore 12, as shown in Figure 6. The first setting system 24 remains attached to the lower end of the second downhole tool 20, such that the toolstring 10 in Figure 6 comprises the first and second setting systems 24, 26 and the second downhole tool 20.

To unset the first downhole tool 16, the toolstring 10 is run in from the second location 28 of Figure 6 to the first location 14 of Figure 7. The first setting system 24 in its unsetting configuration engages the set first downhole tool 16, and releases the first downhole tool 16 from its locking engagement with the bore 12, as shown in Figure 7. The first downhole tool 16 is attached to the first setting system 24, such that the toolstring 10 in Figure 7 comprises the first and second setting systems 24, 26 and the first and second downhole tools 16, 20. To retrieve the first and second downhole tools 16, 20, the toolstring 10 is pulled uphole, as shown in Figure 8. In alternative embodiments, the toolstring 10 is pulled to surface. In further alternative embodiments, the toolstring 10 may be relocated for re-setting (redeployment) of the first and/or second downhole tools.

Figure 9 shows a schematic view of a toolstring 1 10 in accordance with a second embodiment of the invention. The toolstring 1 10 shown in Figure 9 is generally similar to that shown in Figure 1 , and as such like components share like reference numerals, incremented by 100. Accordingly, the toolstring 1 10 comprises a first downhole tool 1 16 and a setting arrangement 122.

In Figure 9, the toolstring 1 10 is located in a bore 1 12 uphole of a setting location 1 14 prior to setting the downhole tool 1 16. The downhole tool 1 16 is at a lowermost end 1 18 of the string 1 10 in the embodiment shown. The setting arrangement 122 comprises a setting system 124 in the embodiment shown. The setting system 124 is located above the downhole tool 1 16. The downhole tool 1 16 is attached at a lower end of the system 124. The toolstring 1 10 is shown in Figure 9 in an uphole location in a setting configuration, prior to setting.

In use, the toolstring 1 10 is run into the bore 1 12 in the configuration shown in Figure 9. Upon reaching a desired setting location 1 14, the downhole tool 1 16 is set, as shown in the transition from Figure 10 to Figure 1 1 . Figure 10 shows the toolstring 1 10 of Figure 9 at the setting location 1 14 prior to setting the downhole tool 1 16. Figure 1 1 shows the downhole tool 1 16 set and locked to the bore 1 12, and detached from the toolstring 1 10. As shown in Figure 1 1 , the toolstring 1 10 is partially retrieved by pulling the toolstring 1 10 uphole of the first location 1 14 after setting the downhole tool 1 16.

Setting the downhole tool 1 16 reconfigures the setting system 124 from a setting configuration to a fishing configuration. Accordingly, the toolstring 1 10 can remain downhole, as shown in Figure 1 1. Tests or operations can be performed with the downhole tool 1 16 set and the toolstring 1 10 detached and located downhole, as shown in Figure 1 1 . For example, an integrity of a seal of the downhole tool 1 16 may be subjected to a pressure test. When it is desired to unset the downhole tool 1 16, such as after the completion of tests or operations, the toolstring 1 10 can be run in from the position of Figure 1 1 to engage and unset the downhole tool 1 16, as shown in Figure 12. The downhole tool 1 16 is re-attached to the setting system 124 and is pulled uphole, as shown in Figure 13.

Figure 14 shows a portion of a toolstring 210 in accordance with a third embodiment of the invention. The toolstring 210 shown in Figure 14 is generally similar to that shown in Figure 9, and as such like components share like reference numerals, incremented by 100. Accordingly, the toolstring 210 comprises a first downhole tool 216 and a first setting system 224 of a setting arrangement 222.

Figure 14 shows the the toolstring portion 210 in a first configuration, prior to setting the first downhole tool 216. In the embodiment shown, the first downhole tool 216 is a plug. The downhole tool 216 has slips 230 and a sealing arrangement 232. The downhole tool 216 shown has an inner recess 234 for receiving a first setting system 224 of the setting arrangement 222. The downhole tool 216 has a first coupling portion 236 for coupling to the first setting system 224 prior to setting the downhole tool 216. The downhole tool 216 has a second coupling portion 238 for coupling to the first setting system 224 prior to setting the downhole tool 216.

In the embodiment shown, the downhole tool 216 is a terminal plug for location at a lowermost end of the toolstring 210. However, in alternative embodiments, it will be appreciated that the tool may be configured for location above other tools. For example, it will readily be appreciated that the toolstring 210 may comprise a second plug above the first setting system 224.

A portion of the first setting system 224 is shown in Figure 14. In particular, a first setting adaptor 223 is shown. The first setting adaptor 223 comprises an main body 240. The main body 240 has an upper coupling portion 242 for coupling the setting adaptor 223 to a setting tool (not shown) of the first setting system 224. In the embodiment shown, the upper coupling portion 242 is attached to the setting tool with a left-hand screw thread.

The setting adaptor 223 houses an inner body 244 within the main body 240. The inner body 244 is coupled at its upper end 246 to an inner shaft (not shown) on the setting tool. A lower end portion 248 of the inner body 244 is coupled to the first coupling portion 236 of the downhole tool 216. The inner body 244 comprises an axial weakness 250 above the lower end portion 248. The axial weakness 250 is an annular recess or neck in the embodiment shown. Accordingly, the inner body 244 is configured to mechanically fail at the weakness 250 under the application of a predetermined tensile force.

The inner body 244 is movable axially within the main body 240. Between the inner body 244 and the main body 240 is a directional gripping arrangement, which is a body lock ring 252 in the embodiment shown. The body lock ring 252 acts as a ratchet mechanism, restricting axial movement of the inner body 244 relative to the main body 240 to one direction, which is a relative uphole movement of the inner body 244 in the embodiment shown.

The main body 240 has a retrieval portion 254 for selectively engaging the second coupling portion 238 of the tool 216. The retrieval portion 254 comprises a retrieval dogs 256 axially spaced from a retaining shoulder 258 in the configuration of Figure 14. Adjacent the retrieval dogs 256 are a setting dogs 260. The retrieval and setting dogs 256, 260 are axially movable with respect to the main body 240. A profile of the main body 240 provides for a radial movement of the retrieval and setting dogs 256, 260 according to their axial displacement relative to the main body 240.

A compression spring 262 exerts an axial force on a dogs housing 264, tending to push the retrieval and setting dogs 256, 260 downhole relative to the main body 240. The main body profile, the second coupling portion 238 of the downhole tool 216 and the radially extended setting dogs 260 provide for an inner radial position of the retrieval dogs 256 in the setting configuration, as shown in Figure 14. Accordingly, the retrieval dogs 256 cannot engage the downhole tool 216 in the setting configuration.

The setting adaptor 223 comprises an outer body or shroud 266 containing the dogs housing 264 and the spring 262 with the adaptor 264. Accordingly, the spring 262 and the dogs housing 264 are protected from loose matter such as debris, ensuring movement of the dogs housing 264.

The setting adaptor 223 comprises a snap ring 268. The snap ring 268 acts as an axial locking mechanism to selectively lock the dogs housing 264 relative to a corresponding recess 270 in the main body 240. The setting adaptor comprises a no- go ring 272 for selectively blocking movement of the dogs housing 264 relative to the main body 240. The no-go ring 272 is selectively releasable using corresponding shear pins 274.

In use, the toolstring 210 is run into a bore in the configuration shown in Figure 14. Upon reaching a desired setting location, the downhole tool 216 is set, as shown in the transition from Figure 14 to Figure 15. To set the tool 216, the setting tool (not shown) is activated. Accordingly, the inner body 244 is pulled uphole relative to the main body 240. Accordingly, the downhole tool 216 is compressed between the first and second coupling portions 236, 238. Compression of the downhole tool 216 causes radial extension of the slips 230 and the sealing arrangement 232. The slips 230 and the sealing arrangement 232 are extended to engage with bore walls (not shown) in a set configuration as shown in Figure 15. With the downhole tool 216 set, as shown in Figure 15, further uphole movement of the inner body 244 relative to the main body 240 is caused by the pulling of the setting tool. As the downhole tool 216 is not further compressible between the first and second coupling portions 236, 238; and the downhole tool 216 is axially locked to the bore by the slips 230, further relative movement of the inner body 244 provides an internal tension within the inner body 244. At a sufficient tension, the inner body 244 breaks at the weakness 250 above its lower end portion 248, as shown in Figure 16. The retrieval dogs 256 are maintained in the radially inner setting configuration by the main body profile, the second coupling portion 238 of the downhole tool 216 and the radially extended setting dogs 260. Accordingly, the setting adaptor 223 is pulled clear of the downhole tool 216, as shown in Figure 17.

With the radial restriction of the second coupling portion 238 of the downhole tool 216 on the retrieval dogs 256 removed; and the continued application of downhole force from the spring 262, the dogs housing 264 is pushed downhole, relative to the main body 240. Accordingly, a tapered shoulder of the profile of the main body 240 forces the retrieval dogs 256 to radially extend, to the position shown in Figure 17. The setting dogs 260 are spring-loaded such that the setting dogs 260 revert to its default inner radial position, as shown in Figure 17.

Accordingly, the setting adaptor 223 is reconfigured from the setting configuration of Figure 14 to a retrieval configuration in Figure 17.

The toolstring 210 can be pulled further uphole than shown in Figure 17. For example, additional tools, such as plugs (not shown) mounted on the toolstring 210 above the setting adaptor 223 can be set at other locations, uphole from that of the set downhole tool 216 in Figure 17.

To unset and retrieve the set tool 216, the toolstring 216 is lowered from the position of Figure 17 to the position of Figure 18. The second coupling portion 238 of the downhole tool 216 engages the retrieval dogs 256. Radial movement of the retrieval dogs 256 is restricted by the profile of the main body 240. Accordingly, the retrieval dogs 256 are moved axially relative to the main body 240, pushing the dogs housing 264 relatively upwards, compressing the spring 262. Further movement of the setting adaptor 223 downwards causes the retrieval dogs 256 to be pushed radially inwards by the second coupling portion 238 of the downhole tool 216 where allowed by the profile of the main body 240, as shown in Figure 19. Accordingly, the retrieval dogs 256 are radially retracted to allow their passage into the inner recess 234 of the downhole tool 216. Once the retrieval dogs 256 have axially passed the second coupling portion 238 of the downhole tool 216 due to the downward passage of the setting adaptor 223, the retrieval dogs 256 are forced axially downwards relative to the main body 240 by the compressed spring 262. Accordingly, the tapered shoulder of the profile of the main body 240 forces the retrieval dogs 256 to radially extend, to the position shown in Figure 20. Accordingly, the retrieval dogs 256 engage the second coupling portion 238 of the downhole tool 216.

To unset the downhole tool 216, the toolstring 210 is pulled uphole. Accordingly, the downhole tool 216 is in tension between the second coupling portion 238 (in engagement with the retrieval dogs 256) and the slips 230 gripping the bore wall. Tension causes extension of the downhole tool 216 between the first and second coupling portions 236, 238, thus causing radial retraction of the slips 230 and the sealing arrangement 232. The slips 230 and the sealing arrangement 232 are retracted to disengage from the bore wall to an unset configuration (not shown).

With the downhole tool 216 unset, the toolstring 210, including the unset downhole tool 216, can be retrieved uphole. For example, the toolstring 210 may be pulled uphole to surface.

In alternative embodiments, it will be appreciated that the toolstring, including the unset tool, can be moved further downhole. For example, where a further setting arrangement is mounted below the first downhole tool 216, the toolstring may be moved downhole to unset a further downhole tool.

In the event that the unset tool 216 becomes stuck in the bore during retrieval, the toolstring 210 is configured to selectively detach the stuck downhole tool 216. A downward application of force causes the shear pins 274 to shear, allowing movement of the no-go ring 272. With the no-go ring 272 released, the dog housing 264 is free to move to disconnect configuration. The main body 240 moves downhole relative to the stuck downhole tool 216 and relative to the engaged retrieval dogs 256 (blocked by a tapered shoulder in the inner recess 234 of the stuck downhole tool 216). The relative movement of the main body 240 and the retrieval dogs 256 and the tapered shoulder in the inner recess 234 force the retrieval dogs 256 radially inwards to disconnect from the downhole tool 216. The release of the no-go ring 272 allows the dog housing 264 to move axially further uphole relative to the main body 240 than previously. Accordingly the snap ring 268 engages the corresponding recess 270. Extension of the dog housing 264 by the spring 262 relative to the main body 240 is prevented. Accordingly, the retrieval dogs 256 are maintained in the radially inner disconnect configuration. The setting adaptor 223 can be pulled from the inner recess 234 of the stuck downhole tool 216, allowing the toolstring 210 to be pulled uphole (without the stuck downhole tool).

It will be appreciated that additional downhole tools and setting adaptors may be mounted to the toolstring. Accordingly a plurality of downhole tools can be set and/or retrieved with the toolstring. For example, the lowermost downhole tool is set first at a furthest downhole location, the toolstring is pulled to a next downhole location, where the next downhole tool is set, and so on until all of the downhole tools are set at the desired locations.

It will be appreciated that any of the aforementioned apparatus may have other functions in addition to the mentioned functions, and that these functions may be performed by the same apparatus.

The applicant hereby discloses in isolation each individual feature described herein and any combination of two or more such features, to the extent that such features or combinations are capable of being carried out based on the present specification as a whole in the light of the common general knowledge of a person skilled in the art, irrespective of whether such features or combinations of features solve any problems disclosed herein, and without limitation to the scope of the claims. The applicant indicates that aspects of the present invention may consist of any such individual feature or combination of features. It should be understood that the embodiments described herein are merely exemplary and that various modifications may be made thereto without departing from the scope of the invention. For example, where two downhole tools are shown, other embodiments may comprise additional downhole tools. Similarly, where two similar downhole tools are shown, such as two plugs, in other embodiments different downhole tools, different combinations of downhole tools, or different types of downhole tool may be provided. Where a tensile spring-loaded setting dog is shown, it will be appreciated that in alternative embodiments a hinged retrieval dog with a torsion spring may be provided. Similarly, in alternative embodiments collet fingers are provided to perform the function of the retrieval dogs. The collet fingers are configured to an inner radial position, with a setting configuration being provided by a force from the downhole tool in a setting configuration (e.g. the fingers are clamped between the downhole tool and the outer body in the setting configuration).

Claims

CLAIMS:

1 . A method of setting first and second downhole tools in a bore comprising:

setting the first downhole tool at a first location;

moving the second downhole tool relative to the set first downhole tool to a second location, where the first location is independent of the second location; and

setting the second downhole tool at the second location.

2. The method of claim 1 , wherein the method comprises setting the first downhole tool with a first setting system of a setting arrangement and setting the second downhole tool with a second setting system of the setting arrangement.

3. The method of claim 2, wherein the method comprises disconnecting at least a portion of the setting arrangement from the toolstring.

4. The method claim 3, wherein method comprises disconnecting the second downhole tool from the toolstring.

5. The method of any preceding claim, wherein the method comprises reconfiguring the toolstring between a setting configuration and an unsetting configuration.

6. The method of claim 5, wherein the method comprises reconfiguring the toolstring from the setting configuration to the unsetting configuration by setting the downhole tool.

7. The method of claim 1 , wherein the method comprises setting of the first tool downhole of the second tool.

8. A downhole toolstring comprising first and second downhole tools, wherein the toolstring is configured to set the first downhole tool at a first location in a bore and the second downhole tool at a second location in the bore, where the first location is independent of the second location, the second downhole tool being movable relative to the set first downhole tool at the first location to the second location.

9. The toolstring of claim 7, wherein the first and/or second downhole tools comprise at least one of:

a plug; and/or

a packer; and/or

a valve; and/or

a flow control device; and/or

a hanger; and/or

a straddle; and/or

a tubing puncher.

10. The toolstring of claim 7 or 8, wherein the second location is remote from the first location.

1 1 . The toolstring of any of claims 7 to 9, wherein the first and second downhole tools are mounted on the toolstring at a transportation distance for running in, wherein the transportation distance is substantially different from a distance between the first and second locations.

12. The toolstring of any of claims 7 - 10, wherein the toolstring comprises a setting arrangement with a first setting system configured to set the first downhole and a second setting system configured to set the second downhole tool.

13. The toolstring of claim 1 1 , wherein the toolstring is configured to disconnect at least a portion of the setting arrangement from the toolstring.

14. The toolstring of claim 12, wherein the toolstring is configured to disconnect at least the portion of the setting arrangement by a predefined mechanical failure.

15. The toolstring of claim 13, wherein the predefined mechanical failure comprises a tensile failure.